Alon USA Partners Reports Second Quarter Results

Transcription

1 August 5, 2013 Alon USA Partners Reports Second Quarter Results Declares Quarterly Cash Distribution Partnership schedules conference call for August 7, 2013 at 10:00 a.m. Eastern DALLAS, Aug. 5, 2013 /PRNewswire/ -- Alon USA Partners, LP (NYSE: ALDW) (the "Partnership") today announced results for the second quarter of Net income for the second quarter of 2013 was $45.3 million, or $0.73 per unit, compared to $100.2 million for the same period last year. Net income for the first half of 2013 was $138.8 million, or $2.22 per unit, compared to $148.3 million for the same period last year. The Board of Directors of Alon USA Partners GP, LLC, the general partner of Alon Partners, declared a distribution of $0.71 per unit payable in cash on August 23, 2013 to common unitholders of record at the close of business on August 16, Cash available for distribution for the three months ended June 30, 2013 totaled $44.1 million. Paul Eisman, CEO and President, commented, "Our Big Spring Refinery had an excellent operational quarter recording its highest ever quarterly crude throughput of 70,807 barrels per day with total throughput of 72,124 barrels per day. We experienced a sharp decline in the WTI to WTS spread, declining approximately $11 per barrel for the second quarter compared to first quarter of The Gulf Coast 3/2/1 crack spreads declined by approximately $7 per barrel for the second quarter compared to first quarter of We are focused on opportunities to improve our assets and are planning a project that will be implemented during the Big Spring turnaround in 2014 that will increase overall distillate yield by 2% and will also increase total refinery throughput by 3,000 barrels per day. "In addition, in the second quarter we were impacted by sharp increases in RINs prices. We recorded approximately $8 million of costs in the second quarter for RINs obligations. We are actively working to mitigate these costs primarily by blending biodiesel into our Big Spring product beginning in September. We anticipate at current RINs pricing that our RINs obligation at Big Spring for the year will be approximately $20 million. "Looking forward to the third quarter, we expect total throughput at Big Spring to average approximately 69,000 barrels per day." SECOND QUARTER 2013 Refinery operating margin was $16.21 per barrel for the second quarter of 2013 compared to $25.79 per barrel for the same period in This decrease is mainly due to lower Gulf Coast 3/2/1 crack spreads and a narrowing WTI to WTS spread. The refinery's throughput for the second quarter of 2013 averaged 72,124 barrels per day ("bpd") compared to 64,558 bpd for the same period in Throughput for the second quarter of 2012 was impacted by downtime for the planned regeneration of our reformer catalyst and replacement of several catalyst beds during the period. The average Gulf Coast 3/2/1 crack spread was $21.17 per barrel for the second quarter of 2013 compared to $26.04 per barrel for the second quarter of The average WTI to WTS spread for the second quarter of 2013 was $0.36 per barrel compared to $5.36 per barrel for the same period in YEAR-TO-DATE 2013 Refinery operating margin was $21.85 per barrel for the first half of 2013 compared to $20.32 per barrel for the same period in This increase is mainly due to a wider WTI to WTS spread partially offset by lower Gulf Coast 3/2/1 crack spreads. The refinery's throughput for the first half of 2013 averaged 65,835 bpd compared to 67,035 bpd for the same period in The average Gulf Coast 3/2/1 crack spread was $24.76 per barrel for the first half of 2013 compared to $25.41 per barrel for the same period in The average WTI to WTS spread for the first half of 2013 was $5.86 per barrel compared to $3.76 per barrel for the same period in CONFERENCE CALL The Partnership has scheduled a conference call which will also be webcast live on Wednesday, August 7, 2013 at 10:00 a.m. eastern time (9:00 a.m. central time), to discuss the second quarter 2013 results. To access the call, please dial or , for international callers, at least 10 minutes prior to the start time and ask for the Alon USA Partners, LP call. Investors may also access the live webcast on the Alon Partners website, by logging on that site and clicking "Investors." A telephonic replay of the conference call

2 will be available through August 21, 2013, and may be accessed by calling , or , for international callers, and using the passcode #. The archived webcast will also be available at shortly after the call and will be accessible for approximately 90 days. For more information, please contact Donna Washburn at Dennard Lascar Associates at or This release serves as qualified notice to nominees under Treasury Regulation Section (b). Please note that 100% of Alon Partners' distributions to foreign investors are attributable to income that is effectively connected with a United States trade or business. Accordingly, all of Alon Partners' distributions to foreign investors are subject to federal income tax withholding at the highest effective tax rate for individuals or corporations, as applicable. Nominees, and not Alon Partners, are treated as the withholding agents responsible for withholding on the distributions received by them on behalf of foreign investors. Alon USA Partners, LP is a Delaware limited partnership formed in August 2012 by Alon USA Energy, Inc. ("Alon Energy") (NYSE: ALJ). Alon Partners owns and operates a crude oil refinery in Big Spring, Texas with total throughput capacity of approximately 70,000 barrels per day. Alon Partners refines crude oil into finished products, which is marketed primarily in West Texas, Central Texas, Oklahoma, New Mexico and Arizona through its wholesale distribution network to both Alon Energy's retail convenience stores and other third-party distributors. Contacts: Claire Hart, Senior Vice President Alon USA Partners GP, LLC Investors: Jack Lascar/ Sheila Stuewe Dennard Lascar Associates, LLC Media: Blake Lewis Lewis Public Relations Ruth Sheetrit SMG Public Relations Tables to follow - ALON USA PARTNERS, LP AND SUBSIDIARIES CONSOLIDATED EARNINGS RELEASE RESULTS OF OPERATIONS - FINANCIAL DATA (ALL INFORMATION IN THIS PRESS RELEASE EXCEPT FOR BALANCE SHEET DATA AS OF DECEMBER 31, 2012, IS UNAUDITED) For the Three Months Ended For the Six Months Ended June 30, June 30, (B) (B) (dollars in thousands, except per unit data, per barrel data and pricing statistics) STATEMENTS OF OPERATIONS DATA: (A) Net sales (1) $ 865,694 $ 823,769 $ 1,669,861 $ 1,708,043 Operating costs and expenses: Cost of sales 767, ,270 1,417,525 1,460,164

3 Direct operating expenses 27,314 25,073 57,736 47,743 Selling, general and administrative expenses 5,065 3,909 12,730 7,754 Depreciation and amortization 11,243 11,424 23,307 23,390 Total operating costs and expenses 810, ,676 1,511,298 1,539,051 Operating income 54, , , ,992 Interest expense (8,970) (5,683) (18,362) (10,757) Interest expense - related parties (4,266) (8,533) Other income (loss), net 14 (4) Income before state income tax expense 45, , , ,719 State income tax expense ,373 1,420 Net income $ 45,321 $ 100,223 $ 138,846 $ 148,299 Earnings per unit $ 0.73 $ 2.22 Weighted average common units outstanding (in thousands) 62,502 62,502 CASH FLOW DATA: Net cash provided by (used in): Operating activities $ (13,403) $ 143,668 $ 153,243 $ 187,143 Investing activities (7,257) (11,823) (13,976) (19,104) Financing activities (143,128) (126,105) (178,584) (262,286) OTHER DATA: Adjusted EBITDA (2) $ 66,007 $ 122,513 $ 181,888 $ 192,399 Capital expenditures 6,216 5,820 9,157 11,042 Capital expenditures for turnaround and chemical catalyst 1,041 6,003 4,819 8,062 KEY OPERATING STATISTICS: Per barrel of throughput: Refinery operating margin (3) $ $ $ $ Refinery direct operating expense (4) PRICING STATISTICS: Crack spreads (per barrel): Gulf Coast 3/2/1 (5) $ $ $ $ WTI crude oil (per barrel) $ $ $ $ Crude oil differentials (per barrel): WTI less WTS (6) $ 0.36 $ 5.36 $ 5.86 $ 3.76 Product price (dollars per gallon): Gulf Coast unleaded gasoline $ 2.69 $ 2.80 $ 2.77 $ 2.89 Gulf Coast ultra-low sulfur diesel Natural gas (per MMBtu)

4 June 30, 2013 December 31, 2012 BALANCE SHEET DATA (end of period): (dollars in thousands) Cash and cash equivalents $ 26,684 $ 66,001 Working capital (24,973) 1,702 Total assets 729, ,423 Total debt 245, ,311 Total partners' equity 192, ,726 (A) Earnings per unit information is not presented for the three and six months ended June 30, 2012 as there was no common equity or potential common equity publicly traded during that period and therefore is not required by Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") topic 260, Earnings per share. (B) The information presented contains the unaudited combined financial results of Alon USA Partners, LP (""), our predecessor for accounting purposes, for the three and six months ended June 30, THROUGHPUT AND PRODUCTION DATA: For the Three Months Ended For the Six Months Ended June 30, June 30, bpd % bpd % bpd % bpd % Refinery throughput: WTS crude 53, , , , WTI crude 17, , , , Blendstocks 1, , , , Total refinery throughput (7) 72, , , , Refinery production: Gasoline 35, , , , Diesel/jet 24, , , , Asphalt 4, , , , Petrochemicals 4, , , , Other 3, , , , Total refinery production (8) 71, , , , Refinery utilization (9) % 98.9 % 97.1 % 97.8 % CASH AVAILABLE FOR DISTRIBUTION DATA: For the Three Months Ended June 30, 2013

5 (dollars in thousands, except per unit data) Net sales $ 865,694 Operating costs and expenses: Cost of sales 767,322 Direct operating expenses 27,314 Selling, general and administrative expenses 5,065 Depreciation and amortization 11,243 Total operating costs and expenses 810,944 Operating income 54,750 Interest expense (8,970) Other income, net 14 Income before state income tax expense 45,794 State income tax expense 473 Net income 45,321 Adjustments to reconcile net income to Adjusted EBITDA: Interest expense 8,970 State income tax expense 473 Depreciation and amortization 11,243 Adjusted EBITDA 66,007 Adjustments to reconcile Adjusted EBITDA to cash available for distribution before special expenses: less: Maintenance/growth capital expenditures 6,216 less: Turnaround and catalyst replacement capital expenditures 1,041 less: Major turnaround reserve 1,150 less: Principal payments 625 less: State income tax expense 473 less: Interest paid in cash 8,296 Cash available for distribution before special expenses 48,206 less: Special turnaround reserve 4,104 Cash available for distribution $ 44,102 Common units outstanding (in 000's) 62,502 Cash available for distribution per unit $ 0.71 (1) Includes sales to related parties of $156,043 and $148,171 for the three months ended June 30, 2013 and 2012, respectively, and $297,942 and $298,734 for the six months ended June 30, 2013 and 2012, respectively.

6 (2) Adjusted EBITDA represents earnings before state income tax expense, interest expense, depreciation and amortization, and gain on disposition of assets. Adjusted EBITDA is not a recognized measurement under GAAP; however, the amounts included in Adjusted EBITDA are derived from amounts included in our consolidated financial statements. Our management believes that the presentation of Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors, and other interested parties in the evaluation of companies in our industry. In addition, our management believes that Adjusted EBITDA is useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of Adjusted EBITDA generally eliminates the effects of state income tax expense, interest expense, gain on disposition of assets and the accounting effects of capital expenditures and acquisitions, items that may vary for different companies for reasons unrelated to overall operating performance. Adjusted EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations are: - Adjusted EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or contractual commitments; - Adjusted EBITDA does not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt; - Adjusted EBITDA does not reflect changes in or cash requirements for our working capital needs; and - Our calculation of Adjusted EBITDA may differ from EBITDA calculations of other companies in our industry, limiting its usefulness as a comparative measure. Because of these limitations, Adjusted EBITDA should not be considered a measure of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using Adjusted EBITDA only supplementally. The following table reconciles net income to Adjusted EBITDA for the three and six months ended June 30, 2013 and 2012, respectively: For the Three Months Ended For the Six Months Ended June 30, June 30, (dollars in thousands) Net income $ 45,321 $ 100,223 $ 138,846 $ 148,299 State income tax expense ,373 1,420 Interest expense 8,970 5,683 18,362 10,757 Interest expense - related parties 4,266 8,533 Depreciation and amortization 11,243 11,424 23,307 23,390 Adjusted EBITDA $ 66,007 $ 122,513 $ 181,888 $ 192,399 (3) Refinery operating margin is a per barrel measurement calculated by dividing the margin between net sales and cost of sales by the refinery's throughput volumes. Industry-wide refining results are driven and measured by the margins between refined product prices and the prices for crude oil, which are referred to as crack spreads. We compare our refinery operating margin to these crack spreads to assess our operating performance relative to other participants in our industry. The refinery operating margin excludes charges of $8,016 related to RINs obligations for the three and six months ended

7 June 30, (4) Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses by total throughput volumes. (5) We compare our refinery operating margin to the Gulf Coast 3/2/1 crack spread. A Gulf Coast 3/2/1 crack spread is calculated assuming that three barrels of WTI crude oil are converted, or cracked, into two barrels of Gulf Coast conventional gasoline and one barrel of Gulf Coast ultra-low sulfur diesel. (6) The WTI/WTS, or sweet/sour, spread represents the differential between the average value per barrel of Cushing WTI crude oil and the average value per barrel of Midland WTS crude oil. (7) Total refinery throughput represents the total barrels per day of crude oil and blendstock inputs in the refinery production process. (8) Total refinery production represents the barrels per day of various refined products produced from processing crude and other refinery feedstocks through the crude units and other conversion units. (9) Refinery utilization represents average daily crude oil throughput divided by crude oil capacity, excluding planned periods of downtime for maintenance and turnarounds. SOURCE Alon USA Partners, LP